Embodiments of the present disclosure include a test dart for wellbore pressure isolation. The test dart includes a body extending from a first end to a second end, the body having a bore extending therethrough, a diameter of the bore being greater at a first end than the second end. The test dart also includes a groove formed proximate the first end and extending radially outward from the bore and into the body. Additionally, the test dart includes an anti-rotation pin positioned between the groove and the second end, the anti-rotation pin extending radially outward from the body. The test dart further includes a check valve positioned in the bore, the check valve enabling flow in a single direction and being moveable between an open position to enable the flow and a closed position to block the flow.
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16. A method for isolating a wellbore, the method comprising:
lowering a test dart into the wellbore, the test dart being coupled to an installation tool;
non-rotationally coupling the test dart to a unidirectional valve arranged in the wellbore via a gravitational force acting on the test dart;
decoupling the installation tool from the test dart;
lowering a removal tool into the wellbore to retrieve the test dart;
non-rotationally coupling the removal tool to the test dart; and
withdrawing the test dart from the wellbore.
10. A system for isolating regions of a wellbore, the system comprising:
a unidirectional valve positioned in the wellbore, the unidirectional valve permitting a fluid flow in a downstream direction into the wellbore and restricting the fluid flow in an upstream direction out of the wellbore;
a test dart non-rotationally coupled to the unidirectional valve via a gravitational force acting on the test dart, the test dart arranged upstream of the unidirectional valve and positioned to block the fluid flow in the downstream direction toward the unidirectional valve; and
a removal tool, the removal tool non-rotationally coupling to the test dart and positioned to remove the test dart in a non-controlled wellbore environment via a linear force.
1. A test dart for wellbore pressure isolation, comprising:
a body extending from a first end to a second end, the body having a bore extending therethrough, a diameter of the bore being greater at the first end than the second end;
a groove formed proximate the first end and extending radially outward from the bore and into the body;
an anti-rotation pin positioned between the groove and the second end, the anti-rotation pin extending radially outward from the body;
a check valve positioned in the bore, the check valve enabling a flow in a single direction and being moveable between an open position to enable the flow and a closed position to block the flow; and
a pressure relieving orifice in the bore extending radially outwardly into the body.
2. The test dart of
a counter bore positioned axially below the groove;
a slanted edge forming a transition between a change in the diameter of the bore; and
a lock out pin positioned proximate the counter bore, the lock out pin moveable between an extended position and a retracted position such that the lock out pin at least partially extends into the bore when in the extended position.
3. The test dart of
4. The test dart of
5. The test dart of
7. The test dart of
9. The test dart of
11. The system of
12. The system of
13. The system of
14. The system of
15. The system of
17. The method of
18. The method of
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1. Field of Invention
This disclosure relates in general to oil and gas tools, and in particular, to systems and methods for installation of isolation components in a wellbore.
2. Description of the Prior Art
In oil and gas production, components are pressure tested at various stages of drilling, stimulation, completion, and recovery. During testing, various portions of a wellbore may be isolated utilizing valves, packing, or the like. In certain situations, it is desirable to test uphole and surface components. As such, downhole portions of the wellbore may be isolated. Often, isolating downhole components utilizes multiple trips into and out of the well to install and subsequently remove components. These trips lead to rig downtime and can be costly. Moreover, safety regulations may necessitate fully controlled wellbore environments during installation of testing components, further increasing costs. It is now recognized that improved methods for isolation and testing of wellbore components are desirable.
Applicants recognized the problems noted above herein and conceived and developed embodiments of systems and methods, according to the present disclosure, for wellbore pressure isolation.
In an embodiment a test dart for wellbore pressure isolation includes a body extending from a first end to a second end, the body having a bore extending therethrough, a diameter of the bore being greater at a first end than the second end. The test dart also includes a groove formed proximate the first end and extending radially outward from the bore and into the body. Additionally, the test dart includes an anti-rotation pin positioned between the groove and the second end, the anti-rotation pin extending radially outward from the body. The test dart further includes a check valve positioned in the bore, the check valve enabling flow in a single direction and being moveable between an open position to enable the flow and a closed position to block the flow.
In another embodiment a system for isolating regions of a wellbore includes a unidirectional valve positioned in the wellbore, the unidirectional valve permitting a fluid flow in a downstream direction into the wellbore and restricting fluid flow in an upstream direction out of the wellbore. The system also includes a test dart non-rotationally coupled to the unidirectional valve, the test dart arranged upstream of the unidirectional valve and positioned to block the fluid flow in the downstream direction toward the unidirectional valve.
In an embodiment a method for isolating a wellbore includes lowering a test dart into the wellbore, the test dart being coupled to an installation tool. The method also includes coupling the test dart to a unidirectional valve arranged in the wellbore. The method further includes decoupling the installation tool from the test dart.
The present technology will be better understood on reading the following detailed description of non-limiting embodiments thereof, and on examining the accompanying drawings, in which:
The foregoing aspects, features and advantages of the present technology will be further appreciated when considered with reference to the following description of preferred embodiments and accompanying drawings, wherein like reference numerals represent like elements. In describing the preferred embodiments of the technology illustrated in the appended drawings, specific terminology will be used for the sake of clarity. The present technology, however, is not intended to be limited to the specific terms used, and it is to be understood that each specific term includes equivalents that operate in a similar manner to accomplish a similar purpose.
When introducing elements of various embodiments of the present invention, the articles “a,” “an,” “the,” and “said” are intended to mean that there are one or more of the elements. The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements. Any examples of operating parameters and/or environmental conditions are not exclusive of other parameters/conditions of the disclosed embodiments. Additionally, it should be understood that references to “one embodiment”, “an embodiment”, “certain embodiments,” or “other embodiments” of the present invention are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features. Furthermore, reference to terms such as “above,” “below,” “upper”, “lower”, “side”, “front,” “back,” or other terms regarding orientation are made with reference to the illustrated embodiments and are not intended to be limiting or exclude other orientations.
Embodiments of the present disclosure are directed to systems and methods for isolating regions of a wellbore. In certain embodiments, a unidirectional valve is arranged within a wellbore, for example, coupled to a hanger. During operation, certain portions of the wellbore, such as the area above the unidirectional valve, may be independently pressure tested. A test dart may be installed in the wellbore to couple to the unidirectional valve to facilitate the testing. In embodiments, the test dart may be installed in an open or non-controlled wellbore to thereby reduce costs and the time for installation. For example, the test dart may be installed into the wellbore and couple to the unidirectional valve via the gravitational force acting on the test dart. In certain embodiments, the test dart may include one or more anti-rotation pins to substantially reduce the likelihood that rotational forces applied to the test dart may be transmitted to the unidirectional valve, potentially unseating the unidirectional valve from the hanger. Additionally, the running threads of the test dart may be in a direction substantially opposite the running threads of the unidirectional valve. As such, rotation applied to the test dart may not be transmitted to the unidirectional valve. The test dart may also include a lock out pin to block access to one or more threaded components in the test dart, thereby further reducing the likelihood of transmitting rotational forces to the unidirectional valve. In operation, the test dart may be installed and seated on the unidirectional valve. During recovery, a removal tool may be installed into the wellbore and non-rotationally couple to the test dart, for example via spring-loaded pins. As a result, the test dart may be removed utilizing a pulling, non-rotational force to thereby reducing the likelihood of unseating the unidirectional valve. In embodiments, installation and removal are both done in a non-controlled wellbore, thereby reducing the time for installation and reducing costs.
The illustrated unidirectional valve 10 has a poppet valve 24 that may include a flange 26 and an elongate member 28 that extends from the flange 26 to or near a bottom end 30 of the unidirectional valve 10. The flange 26 may have a seal 32 that blocks fluid from passing between the flange 26 and a shoulder 34 on a body 36 of the unidirectional valve 10. In the illustrated embodiment, a spring 38 surrounds at least a portion of the elongate member 28 to help control the movement of the poppet valve 24. In operation, as fluid flows in the downstream direction 18, the spring 38 is compressed and the flange 26 is driven away from the shoulder 34 to enable fluid flow past the elongate member 28 and through the bore 12. The spring 38 is biased so that absent the external force, for example from a fluid flow, the flange 26 is driven against the shoulder 34. It should be appreciated that while the illustrated unidirectional valve 10 includes the poppet valve 24, in other embodiments the unidirectional valve 10 may be a ball check valve, a spring check valve, diaphragm check valve, a swing check valve, a stop check valve, a lift check valve, or any other reasonable device that enables flow in a direction and blocks flow in an opposite direction.
During oil and gas operations, different portions of the wellbore may be isolated in order to conduct pressure testing to evaluate potential leakage points. For example, a wellhead assembly 40 which may include a tree, blow out preventer (BOP) or the like arranged uphole from the unidirectional valve 10. Prior to operations, such as completion or production operations, the components of the wellhead assembly 40 may be pressure tested independently of the remainder of the wellbore. As will be described in detail below, embodiments of the present disclosure include the unidirectional valve 10 configured to receive a test dart that may be installed in a non-controlled environment (e.g., without a lubricator, in an open hole environment, at substantially atmospheric pressure, etc.) to enable faster and more cost-effective installation and removal of the test dart. In other words, a primary pressure barrier (e.g., the unidirectional valve) is not removed from the wellbore during downhole operations and therefore at least one pressure controlling device remains in position to control pressure from the wellbore. Furthermore, in embodiments, the test dart may include one or more features to block rotation and thereby enable installation and removal using pushing and pulling forces, thereby reducing the likelihood of unseating the unidirectional valve 10 from the hanger 14.
The illustrated unidirectional valve 10 includes the body 36 and the flange 26 coupled to the elongate member 28 extending substantially to the bottom end 30 of the unidirectional valve 10. In the illustrated embodiment, the elongate member 28 is at least partially surrounded by the spring 38 to bias the flange 26 in an upstream direction 20, thereby driving the unidirectional valve 10 into the illustrated closed position 50. When in the closed position 50, the flange 26 is arranged in contract with the shoulder 34. Moreover, the seal 32 is urged against the shoulder 34 thereby blocking fluid from flowing in the upstream direction 20.
The unidirectional valve 10 includes an upper portion 52 that at least partially forms a through bore 54 extending from a top end 56 to the bottom end 30. The top end 56 includes a lip 58 extending longitudinally downward and a load shoulder 60 extending radially inward from the lip 56. The load shoulder 60 has a downwardly sloped surface and is utilized to form a seal between a test dart and the unidirectional valve 10. As illustrated in
As shown in
The illustrated test dart 80 includes an internal check valve 104. As shown, the internal check valve 104 is secured to the test dart 80 via a rod 106. The check valve 104 includes an aperture 108 that enables a flange 110 to move axially along an axis 112. Movement of the check valve 104 is substantially blocked in the downstream direction 18 in the embodiment illustrated in
The test dart 80 illustrated in
In certain embodiments, the installation tool 130 is coupled to the test dart 80 at the surface of the wellbore thereby enabling an operator to pull the lock out pin 98 out of the bore 84. The lock out pin 98 is accessible through the notch 100 when the test dart 80 is at the surface. Accordingly, the operator may clear the bore 84 for installation of the installation tool 130. Thereafter, the installation tool 130 can be lowered into the bore 84 and secured via the threads 102, 138. In the illustrated embodiment, a downward facing shoulder 142 of the installation tool 130 contacts the first end 86 of the test dart 80 when the installation tool 130 is fully installed. This may serve as an indicator to the operator that the threads 102, 138 are fully engaged. However, it should be appreciated that in other embodiments the installation tool 130 may not contact the first end 86 of the test dart 80.
In the illustrated embodiment, the installation tool 130 includes a groove 144, which may be a thread relief. As shown in
In the embodiment illustrated in
Although the technology herein has been described with reference to particular embodiments, it is to be understood that these embodiments are merely illustrative of the principles and applications of the present technology. It is therefore to be understood that numerous modifications may be made to the illustrative embodiments and that other arrangements may be devised without departing from the spirit and scope of the present technology as defined by the appended claims.
Olvera, Alfred, Warner, John, Borak, Eugene, Garner, Detrick Deyon, Armistead, Jason, Cheng, Samuel, Burcham, Nathan
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Aug 07 2017 | BORAK, EUGENE | GE OIL & GAS PRESSURE CONTROL LP | ASSIGNMENT OF ASSIGNORS INTEREST SEE DOCUMENT FOR DETAILS | 043355 | /0038 | |
Aug 07 2017 | BURCHAM, NATHAN | GE OIL & GAS PRESSURE CONTROL LP | ASSIGNMENT OF ASSIGNORS INTEREST SEE DOCUMENT FOR DETAILS | 043355 | /0038 | |
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Aug 21 2017 | CHENG, SAMUEL | GE OIL & GAS PRESSURE CONTROL LP | ASSIGNMENT OF ASSIGNORS INTEREST SEE DOCUMENT FOR DETAILS | 043355 | /0038 | |
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